Methods and means for resolving petroleum emulsion streams



April 19, 1960 WALKER ETAL METHODS AND MEANS FOR RESOLVING PETROLEUM EMULSION STREAMS Filed May 13, 1957 2 Sheets-Sheet 1 Em w mn \U.P m a w 55m; 1 a m 2232 3 4 522188 .Eu: 0: U c 25 6 3m: 2 P l. m. 8 moSmEum mwmmmm 050-4 2450 mmmJ Jay R Walker Clarence 0. Glasgow BY Jasiph L. Maher ATTORNEY-'8 April 19, 1960 J. P- WALKER ETAL 2,933,447

' METHODS AND MEANS FOR RESOLVING PETROLEUM EMULSION STREAMS Filed May 13, 1957 2 Sheets-Sheet 2 S S R Y v E m M m ..E g 0 i 55; v s r n mm m f A 15 =o m muwzsfivxm uI 2430 www W ML ya (wm oi'fil. P MM, M w y w x 44w; W M 5 muEuE United States Patent METHODS AND MEANS FOR RESOLVING PETROLEUM EMULSION STREAMS .lay P. Walker, Clarence 0. Glasgow, and Joseph L.

Maher, Tulsa, Gkla, assignors to National Tank Company, Tulsa, Okla, a corporation of Nevada Application May 1'3, 1957, Serial No. 658,840

19 Claims. (Cl. 208-187) a This invention relates to new and useful improvements in methods and means for resolving petroleum emulsion streams.

The invention is particularly concerned with improvements in methods and means of breaking the oil and water emulsions which often occur in petroleum well streams, conserving the lighter hydrocarbons which are driven off from the oil by the heating thereof, and especially, in achieving a degree of stabilization of the recovered oil to prevent subsequent losses by evolution of gas, and hence, torecover larger quantities of oil of higher gravity.

At the present time, it is the practice to treat or break oil field emulsion streams, with or without the addition of emulsion breaking chemicals thereto, by heating the emulsion and permitting it to separate and stratify into water and clean oil layers. light and intermediate fractions of the oil may be driven oil by the heat and subsequently lost to recovery, or else, such fractions may be condensed along with an excessive gas content, or the emulsion insufficiently heated to drive off gas therefrom, all with the net result that the clean oil passes to storage with an excessive gas content which evolves or flashes from the clean oil in the storage tanks and carries with it desirable hydrocarbons. The net result is the lossof valuable, recoverable hydrocarbons either in the gas outlet from the treating vessel or in the vents from the storage tanks.

It is, therefore, a principal object of this invention to provide an improved method and means for the treating of petroleum emulsion streams which places larger quantities of recoverable and retainable liquid hydrocarbons in the storage tanks and avoids excessive loss from the tanks by gas vaporization.

It is a further object of the invention to pass the well stream first through a separation stage in which a preliminary gas and liquid separation is made at a pressure higher than the subsequent treating stage, and thereafter to pass the separated liquids into a treating stage having provision for stabilization of the recovered clean oil.

A still further object of the invention is to provide improved methods and means of the character described in which separated liquids are taken from one portion of the separation stage and introduced into the treating zone of the treating stage, a second portion of the separated liquids, preferably with cooling, being introduced into a stabilization zone of the treating stage for effective absorption of valuable hydrocarbons which may be evolved from the treating zone.

Other and more particular objects will be apparent from a reading of the following description and specification.

A construction designed to carry out the invention will be hereinafter described, together with other features of the invention.

The invention will be more readily understood from a reading of the following specification and by reference to In this process, certain of the 12,933,447 Patented Apr. 19, 1960 the accompanying drawings, wherein examples of the invention are shown, and wherein:

Fig. l is a schematic view illustrating an emulsion treating structure constructed in accordance with this invention and adapted to carry out the methods hereof,

Fig. 2 is a fragmentary view of the upper portion of a modified form of the emulsion treating structure, and

Fig. 3 is a schematic view of a further modification of the emulsion treating apparatus adapted to carry out the methods of this invention.

In the drawings, the numeral 10 designates a petroleum well from which a Well stream flows through a conductor 11 to an oil and gas separator12. The latter may be of any suitable or desirable structure having a gas outlet conductor 13 with suitable means, such as the valve 14, for maintaining the desired pressure within the separator 12. A separated liquids outlet conductor 15 leads from the lower portion of the separator through a conventional float-controlled valve 16 into a heat exchanger 17 having a jacket or shell 18 adapted to receive a warm liquid, and having the conductor 15 extending through said jacket for heat exchange with said warm liquid. The discharge end 19 of the conductor 15 is connected into an emulsion treating or resolving structure 2! as will be described more fully hereinafter.

A second separated liquids outlet conductor 21 is connected into the separator 12 above the point of discharge through the conductor 15, desirably being in communication with the upper portion or section of the body of separated liquids 22 accumulated within the separator and maintained at a relatively constant or predetermined liquid level 23 by means of the float-controlled valve 16. Desirably, the outlet conductor 21 withdraws liquids from the body 22at a point spaced fairly closely below the surface 23 thereof so as to receive preferentially the clean or cleaner oil which may be present, as well as the lighter portions of any emulsions present and the. sand-free liquids. The sand-laden liquid and heavier emulsified portions will tend to gravitate to the bottom of the body of liquids 22 and be withdrawn through the outlet condoctor 15. Hence, the positioning of the outlet conductor 21 near or in the upper portion of the body of separated liquids 22 causes a relatively clean petroleum to be discharged through the conductor 21, that is, a liquid more nearly approaching the nature and characteristics of fairly clean oil. 7

The conductor 21 extends to a suitable cooler 24 which may be supplied with a refrigerant, with cooling water, or with any other suitable or desirable cooling medium for decreasing the temperature of the petroleum stream passing therethrough. From the cooler 24, the withdrawn portion of the well stream is carriedthrough a conductor 25 and a control valve 26 into the upper portion of the emulsion treating structure 20. Since the separator 12 is operated at a higher pressure than the emulsion treating structure 20, the separated liquids dlow readily under the impetus of this pressure differential through the conductors 21 and 15 into the emulsion treating structure, the rates of flow through the two conductors being controlled respectively by the valves 26 and 16. The valve 16, of course, functions to maintain the substantially constant body of liquids 22 within the separator 12, while the control valve 26, as will appear more fully hereinafter, is responsive to temperature within the emulsion treating structure to supply controlled quantities of cooled petroleum fluids thereto.

While the emulsion treating structure 20 may be of any suitable or desirable design or configuration, and may be incorporated in either a vertical or a horizontal vessel, the particular embodiment of the invention illustrated in the drawings includes an upright vertical shell or vessel 27 closed at'its upper end by a head 28 and at its lower end by a dished bottom 29 mounted upon a :suitable support 30. A transverse partition 31 extends :across the upper portion of the vessel below the head 28 and encloses with the head a preliminary separation chamber A. A second partition 32 extends across the intermediate portion of the vessel 27 below the partition 31 and encloses with the latter partition a stabilizing chamber B. The portion below the partition 32 forms a heating and settling chamber C for final breaking or resolution of the emulsion stream and may be of any suitable or desirable design and construction. As shown in Fig. l, the treating section includes the conventional heating or fire tube 33 and a flume or downwardly-directed pipe 34 for conducting the emulsion stream into the lower portion of the chamber C and releasing it beneath the fire tube for heating and resolution into water and clean oil.

The conductor 25 discharges into the compartment A through a spreader or diverter box 35 which desirably spreads the incoming petroleum stream circumferentially over the walls of the chamber A in order to scrub quantities of gas therefrom. The partially degassified petroleum fluids then gravitate downwardly onto the partition 31 for subsequent flow into the chamber B. It is noted that the partition 31 will be maintained rela- .tively cool by reason of the presence of the incoming well fluids which flow thereover, these fluids having previously been chilled or cooled in the cooling unit 24 so as to pass over the partition 31 and to pass downwardly atherethrough at somewhat lowered temperatures.

Similarly, the second or heavier portion of well fluids, or the liquids comprising predominantly the emulsion stream, enter the chamber B through the conductor 19 and encounter a spreader or diverter box 36 similar to the box 35 for spreading these fluids over the walls of the chamber B to aid in evolution of gas therefrom. These fluids flow downwardly within the chamber B onto the partition 32, thus maintaining the partition 32 at the temperature of said fluids, and then pass downwardly into the emulsion treating chamber C through the flume 34 which has its upper end connected into the partition 32 to furnish a drain therefrom.

Within the chamber C, the well fluids and emulsion stream are heated by passing upwardly over the fire tube 33, after which the fluids accumulate within the upper portion of the chamber C and stratify into their water and clean oil components. The water is withdrawn from the bottom of the chamber C through the water outlet conductor 37 which may include a float controlled valve (not shown), water leg structure (not shown), or any other suitable or conventional means for withdrawing water from the chamber C at approximately the rate at which the water accumulates therein. The clean oil, being the lightest of the liquid components within the emulsion treating chamber C stratifies at the upper portion thereof and is drawn off through the clean oil outlet 38 for conduction through the shell 18 of the heat exchanger 17, and is discharged from the shell through the outlet pipe 39 leading to storage tanks or other point of retention of the clean oil.

The presence of the fire tube Within the treating chamber C will necessarily result in the evolution of hydrocarbon vapors from the well stream, and it is desirable that the retainable or heavier fractions of these vapors be condensed and retained while at the same time eliminating from the entire body of clean recovered oil those lighter fractions and fixed gases, such as methane and ethane, which may not readily be retained in conventional storage tanks. Some condensation of vapors will occur on the underside of the relatively cool head 32, and such condensed vapors will be returned into the clean oil layer for discharge through the outlet conductor 38. The bulk of the vapors, however, will pass upwardly. through a gas vent pipe 40 extending upwardly 4 within the chamber B from the partition 32 to a point closely beneath the partition 31. Thus, the evolved gases and vapors will be carried into the upper portion of the chamber B for partial condensation therein as well as stabilization of the fluids passing downwardly from the chamber A.

For efiecting this combined condensing and stabilizing operation, a contacting or stabilizing structure similar to a fractionating column or tower, is provided within the chamber B and includes a housing 41 depending from the partition 31 and having therein a plurality of contactor or bubble trays 42 provided with downcomers 43 and bubble caps or other contactor structures 44. The cool well fluids introduced into the chamber A will pass successively through the downcomers 43 and over the trays 42 before discharging from the open bottom 45 of the contactor structure, while the gases and vapors present within the chamber B will pass upwardly through the contactor structures 44 and be subjected to the condensing action of the bodies of liquid present on the trays 42. At the same time, the upward passage of the gases and vapors will result in some stripping or stabilizing of the layers of liquid present on the trays whereby the heavier, retainable hydrocarbon fractions are brought into the liquid state, while the lighter hydrocarbon fractions and fixed gases pass upwardly into the chamber A through the vent pipe 46 extending upwardly from the partition 31 in registry with the unit 41. Of course, gases evolved in the chamber B from the liquids entering through the conductor 19 will also be subjected to this action while the combined liquid streams from the conductors 19 and 25 will ultimately gravitate to the partition 32 for passage downwardly into the treating chamber C. Both the heads 31 and 32 function as condensing heads in that they are maintained at a comparatively cool temperature, as compared to the temperature of the gases evolved from the treating chamber C, and hence, condensation of vapors may and does occur on the underside of each head. The principal and most beneficial result which is obtained, however, occurs by reason of the passage of all of the gases evolved in the chambers B and C upwardly in countercurrent relation and intimate contact with the relatively cool and clean petroleum liquids passing downwardly into the chamber B from the chamber A. Thus, the desired hydrocarbon fractions are condensed or liquefied, while the lighter, less desirable hydrocarbon fractions are stripped or removed from the liquid portion of the well stream, and a stable product of maximum gravity and volume is ultimately recovered. Of course, the separated gases may be removed from the treater structure 20 in any suitable or desirable manner, there being shown a gas outlet pipe 47 having therein a suitable control valve 48 for maintaining a predetermined pressure upon the emulsion treating structure 2%.

The flow of the relatively cool petroleum liquids into the chamber A through the conductor 25 may be carried out in differing fashions, one modification being shown in Fig. 1 of the drawings in which a temperaturesensitive or detecting bulb 49 is positioned within the chamber A and controls the opening and closing of the valve 26 through the diaphragm 50 thereof, or through any other suitable or desirable means. Thus, relatively cool well fluids are admitted to the chamber A as required to maintain the internal temperature thercoi at the desired level, all of the separated gas is subjected to this desired temperature level, and a stabilizing liquid refiux or absorbant is supplied to the stabilizing structure 41 under the desired temperature conditions. Obviously, by adjustment of the temperature-sensing struc ture 49, any desired temperature may be maintained in the chamber A in accordance with the ability of the cooler 24 to achieve sufiicient cooling to produce such temperatures.

In Fig. 2, there is illustrated a modification of the temperature controlling means, there being employed in this instance a differential temperature controller 510i the usual and well-known-type and having temperature-sensing connections 52 and 53 connected into the gas outlet conductor 47 and the well liquid supply pipe 25 upstream of the valve 26, respectively. In accordance with usual practice, the unit 51 senses the temperature of the influent liquid in theconductor 25 and'regulates the valve 26 to maintain a predetermined or preset temperature differential between the outgoing gas and the incoming liquid. 7 a

In the form of the invention illustrated in Fig. 3, essentially the same system and structures are employ'ed with the temperature control system of Fig. 2 being utilized, but a somewhat modified form of the emulsion treating structure is shown. The structurev includes an upright vertical tank or vessel 54 with a closed top 55 and bottom 56 carried upon a supporting structure 57.

An intermediate partition or head 58 forms the top wall of the lower or emulsion treating chamber D within the intermediate and bottom portion of the vessel 54, and the bottom wall of the stabilizing chamber E enclosed within the upper portion of the vessel. A frusto-conical partition 59 spaced'a short distance below the head 55 encloses with the head a preliminary separation chamber F in the uppermost portion of the vessel, and it is into this latter chamber that the conductor 25 discharges the relatively clean well fluids withdrawn from the upper portion of the body of separated liquids 22 in the separator 12 through the outlet conductor 21. The partition 59 carries a stabilizing structure 6% somewhat similar to the structure 41 and having a plurality of stabilizing trays 61 carrying bubble caps or other liquid gas contacting means 62. The open upper end of the assembly 6% opens into the chamber F through the partition 59, and hence, liquids introduced into the chamber F flow downwardly through the stabilizer structure and pass from tray to tray thereof by means of the downcomers 63 in the fashion usual and customary in stabilizing or bubble towers.

The conductor 19 is connected into the side wall of the chamber E into a diverter box 64 which directs incoming liquids circumferentially of the wall of the chamber E, and which also is provided with a gas vent or equalizer pipe 65 extending upwardly within the chamber F into close adjacency withthe top head 55 of the vessel 54. A drain conductor 66. extends from the bottom of the chamber B through the partition 58 and thence through theside wall of the vessel 54 into the tube side of a tube and shell heat exchanger 67. At the lower end of the heat exchanger, a conductor directs fiuids received from the conductor 66 into the lower portion of the chamber D beneath a stratifying and bafiling partition 69, from which the liquids flow upwardly into adjacency with the fire tube 70. If desired, a pair of spaced, perforated plates 71 may be positioned within the chamer D above the fire tube to enclose a body of filtering material 72, such as hay, wood excelsior or the like, for coalescing and aiding in the separation and Stratification of the water and clean oil constituents of the emulsified well stream. The clean oil is withdrawn from the upper portion of the chamber D through an outlet conductor 73 leading to the shell side ofthe heat exchanger 67, the cooled clean oil leaving the lower portion of the heat exchanger through a pipe 74' connected intothe heat exchanger 17 similarly to the conductorsb.

Gases and vapors evolved in the chamber D are taken upwardly through'the partition 58 by a pipe 75 which extends upwardly into the chamber E and is connected through the side wall of the stabilizing assembly 69 at a point above the lowerend thereof. Thus, these vapors are subjected first to the condensing actio'nof the partition 58, and are then conducted upwardly in countercurrent flow with the liquids passing downwardly through the assembly 60 from the compartment F.

A gas outlet 76 extends from the side wall of the chamber F and carries a temperature sensing probe 77 similar to the probe 52 and being connected into a differential temperature controller 78 which operates and controls the valve 79 provided in the inlet conductor 25. A temperature-sensing probe 80 is also positioned in the pipe 25 upstream of the valve 79 and connected to the controller 78 for operation of the valve 79 in the manner previously described.

In this form of the invention, the vapors and gases evolved in the lower chamber D are conducted upwardly and into the stabilizer structure 60 wherein the gases and vapors commingle with gases and vapors separated within the chamber E from the liquids entering through the pipe 19. These combined gaseous portions flow upwardly in countercurrent relationship to the relatively cool and clean liquids passing downwardly from the compartment F in order to condensedesirable fractions of the gaseous portions-as well'as to strip or stabilize the downwardly-flowing liquids. All of the separated gas ultimately fiows into the compartment F and is therein commingled for such condensation as may take place prior to withdrawal through the gas outlet 76. Here again, selective condensation of vapors and relatively efiicient stabilization of the separated liquids results.

All of the separated liquids pass downwardly through the pipe 66 into heat exchange relationship in the heat exchanger 67 with the warm clean oil whereby the oil is cooled and the well stream components are preheated prior to introduction into the lower portion of the chamber D. In flowing upwardly over the fire tube 79 and in being heated thereby, the well stream components are caused to separate into water and clean oil portions which stratify within the chamber D for withdrawal. The separated water is, of course, withdrawn through the outlet conductor 81 which is similar to the outlet conductor 37 of Fig. 1 and may be controlled in the same or a similar manner.

In all of the formsflof the invention, the well stream is first introduced into the separator 12 which may, for example be operated at a pressure of 25 to 50 pounds per square inch, and in which quantities of gas are withdrawn from the well stream. Normally the stream is not completely emulsified but will contain some clean or unemulsified oil which will gravitate to the upper portion or section of the accumulated body of liquids '22. This relatively clean oil is then withdrawn as an absorption liquid and carried to the upper portion of the emulsion treating structure for downward flow through the stabilizing unit. The free water, dirtyoil, and heavier emulsified oil and water is withdrawn from the lower portion of the separator 12 and conducted into the intermediate or stabilizing chamber for release of gas therefrom and ultimate down- .ward flow into the emulsion breaking chamber in the lower portion of the treating structure. The gases and vapors evolved in the treating chamber as well as those evolved in the stabilizing chamber are commingled and passed upwardly through the stabilizing unit for selective absorption of desirable hydrocarbon components by the downwardly-flowing, relatively clean oil, and at the same time, the latter is subjected to the stripping or stabilizing action of the upwardly-flowing gases and vapors. The net result is the separation and withdrawal of gas containing relatively few retainable components, and the production of separated clean oil from which the very light hydrocarbons have been stripped or removed whereby the oil may be retained in storage without excessive loss of gas and vaporization of desirable and retainable components. In this manner, the separated gas is rather completely denuded of liquefiable hydrocarbons, and increased volumes of higher gravity oil are recovered for ultimate sale or use.

rator 12, being maintained at a pressure of approximately 10 pounds per square inch, for instance, when the separator 12 is operated at a pressure of 20 pounds per square inch, and a treating temperature of 130 Fahrenheit is being maintained in the lower, emulsion breaking chamber of the treater structure. The invention finds its most eflcctive use with oils and well streams which do not require exceptionally high treating temperatures such as, as an example, emulsion streams which may be effectively treated and broken at temperatures of 100 degrees Fahrenheit to 150 degrees Fahrenheit. At the same time, however, the invention is not to be limited to any particular temperature ranges, and its use is of benefit in treating well streams at any temperature in order to recover increased quantities of oil of higher gravity.

The separator 12 may be of any suitable or desirable type, may be a simple oil and gas separator, or may be an oil, water and gas separator or any other type of vessel in which selective separation of the well stream components is carried out. The important requirement for the separator is that it have provision for withdrawing a relatively clean liquid portion to function as reflux or absorbent liquid within the stabilizing unit. Of course, within the stabilizing unit, the relatively clean liquid portion is brought into intimate and direct heat exchange and stabilizing relationship with gases and vapors evolved in the emulsion-treating zone to produce ultimately maximum volumes of stable or retainable oil and thoroughly denuded gas.

The emulsion breaking section of the treater structure is also subject to much variation in accordance with the many and well-known types of treating units.

The foregoing description of the invention is explanatory thereof and various changes in the size, shape and materials, as well as in the details of the illustrated construction may be made, within the scope of the appended claims, without departing from the spirit of the invention.

What we claim and desire to secure by Letters Patent is:

1. The method of treating and stabilizing emulsified petroleum well streams including the steps of, flowing the well stream into a separation zone wherein the well stream separates into gaseous and liquid portions, accumulating a body of separated liquid in the separation zone, withdrawing heavier liquid from the lower portion of the body of liquid and flowing the heavier liquid to an emulsiontreating zone, heating the heavier liquid in the emulsion treating zone whereby said heavier liquid separates and stratifies into water and clean oil layers and evolves gases and vapors, withdrawing water and clean oil from the stratified layers, withdrawing lighter liquid from the upper portion of the body of liquid and flowing the lighter liquid to a stabilizing zone, flowing gases and vapors evolved in the emulsion treating zone countercurrently with the lighter liquid in the stabilizing zone, withdrawing gas from the stabilizing zone, and flowing the lighter liquid from the stabilizing zone to the emulsion treating zone.

2. The method as set forth in claim 1, separating gas from the heavier liquid and the lighter liquid subsequent to their withdrawal from the separating zone, and commingling the separated gases with the gases evolved in the emulsion treating zone.

3. The method as set forth in claim 1, wherein the separating zone is maintained at a higher pressure than the stabilizing and emulsion treating zones.

4. The method of treating and stabilizing emulsified petroleum well streams including the steps of, flowing the well stream into a separation zone wherein the well stream separates into gaseous and liquid portions, accumulating a body of separated liquid in the separation zone, withdrawing heavier liquid from the lower portion of the body of liquid and flowing the heavier liquid to an emulsion-treating zone, heating the heavier liquid in the emulsion treating zone whereby said heavier liquid separates and stratifies into water and clean oil layers and evolves gases and vapors, withdrawing water and clean oil from the stratified layers, withdrawing lighter liquid from the upper portion of the body of liquid and flowing the lighter liquid to a stabilizing zone while cooling said lighter liquid, flowing gases and vapors evolved in the emulsion treating zone countercurrently with the lighter liquid in the stabilizing zone, withdrawing gas from the stabilizing zone, and flowing the lighter liquid from the stabilizing zone to the emulsion treating zone.

5. In an emulsion treating process in which a petroleum well stream is preliminarily separated into liquid and gaseous bodies and the liquid body is withdrawn for heating to break any emulsion present therein, the improvement including dividing the liquid body into cleaner and less clean portions, passing the less clean portion to the heating step, and passing the cleaner portion in direct contact and flow with gases and vapors evolved in the heating step.

6. In an emulsion treating process as set forth in claim 5, and flowing the cleaner portion of liquid to the heating step subsequent to the passage of the cleaner liquid in contact with the gases and vapors.

7. In an emulsion treating process in which a petroleum well stream is preliminarily separated into liquid and gaseous bodies and the liquid body is withdrawn for heating to break any emulsion present therein, the improvement including dividing the liquid body into cleaner and less cleaner portions, separately removing gas from each portion, passing the less cleaner portion to the heating step, passing the cleaner portion in direct contact and flow with gases and vapors evolved in the heating step, and commingling the removed gases from the two portions.

8. In a petroleum emulsion treating process in which a petroleum well stream is preliminarily separated into liquid and gaseous bodies and the liquid body is withdrawn for heating to break any emulsion present theerin, the improvement including dividing the liquid body into cleaner and less clean portions, separately removing gas from each portion at a pressure lower than that of the preliminary separation step, passing the less clean portion to the heating step, passing the cleaner portion in direct contact and flow with gases and vapors evolved in the heating step, and commingling the removed gases from the two portions.

9. A petroleum emulsion treating and stabilizing structure including, a gas and liquid separator having a well stream inlet and a gas outlet, means for maintaining a body of separated liquid in the separator, a first outlet for withdrawing a first portion of liquid from the upper part of the body of liquid, a second outlet for withdrawing a second portion of liquid from the lower part of the body of liquid, a stabilizing structure for bringing gas and liquid in direct and dispersed contact, means for flowing the first portion of liquid from the first outlet to and through the stabilizer structure, means for flowing the second portion of liquid from the second outlet and commingling said second portion with the first portion subsequent to the passage of the latter through the stabilizer structure, an emulsion-treating enclosure, means for flowing the commingled liquid portions to the emulsion treating enclosure, a heater in the enclosure, means for flowing gas and vapors evolved in the enclosure to and through the stabilizer structure, and means for withdrawing gas and water and clean oil from the structure.

10. A structure as set forth in claim 9, and a cooler in the means for flowing the first portion of liquid to the stabilizer structure.

11. A petroleum emulsion treating and stabilizing structure including, a gas and liquid separator having a well stream inlet and a gas outlet, means for maintaining a body of separated liquid in the separator, a first outlet for withdrawing a first portion of liquid from the upper part of the body of liquid, a second outlet for withdrawing a second portion of liquid from the lower part of the body of liquid, a stabilizer structure for bringing gas and liquid in direct and dispersed contact, a first gas separation enclosure, a second gas separation enclosure, an emulsiontreating enclosure having heating means therein, -means for flowing the first portion of liquid from the first outlet to the first gas separation enclosure, means for fiowing the first portion of liquid from the first gas separation enclosure to and through the stabilizer structure, means for flowing the second portion of liquid from the second outlet to the second gas separation enclosure, means for flowing both portions of liquid from the stabilizer structure and the second gas separation enclosure to the emulsion-treating enclosure, means' for flowing gas and vapors evolved in the emulsion treating enclosure and the second gas separation enclosure to and through the stabilizer structure to the first gas separation enclosure, a gas outlet from the first gas separation enclosure, and water and oil outlets from the emulsion treating enclosure. I

12. A structure as set forth in claim 11, and a cooler in the means for'flowing the first portion of liquid to the first gas separation enclosure.

13. A structure as set forth in claim 11, wherein the stabilizer structure is positioned within the second gas separation enclosure,

14. A structure as set forth in claim 11 wherein the enclosures are formed by a singlevessel having therein two partitions dividing the vessel into the three enclosures.

15. A structure as set forth in claim 11 wherein the enclosures are formed by a single vesesl having therein two partitions dividing the vessel into the three enclosures, and the stabilizing stnucture extends from one partition into the second gas separation chamber.

16. A structure as set forth in claim 11 wherein the stabilizer structure includes a plurality of bubble trays.

17. A structure as set forth in claim 11, a flow control valve in the means for flowing the first portion of liquid to the first gas separation enclosure, and temperature-sensing means responsive to the gas temperature in the first gas separation enclosure for controlling the flow control valve.

.18. A structure as set forth in claim 11, a flow control valve in the means for flowing the first portion of UNITED STATES PATENTS 2,354,856 Erwin Aug. 1, 1944 2,666,019 Winn et al. Jan. 12, 1954 2,768,118 Laurence et al Oct. 22, 1956 

1. THE METHOD OF TREATING AND STABLIZING EMULSIFIED PETROLEUM WELL STREAMS INCLUDING THE STEPS OF, FLOWING THE WELL STREAM INTO A SEPARATION ZONE WHEREIN THE WELL STREAM SEPARATES INTO GASEOUS AND LIQUID PORTIONS, ACCUMULATING A BODY OF SEPARATED LIQUID IN THE SEPARATION ZONE, WITHDRAWING HEAVIER LIQUID FROM THE LOWER PORTION OF THE BODY OF LIQUID AND FLOWING THE HEAVIER LIQUID TO AN EMULSIONTREATING ZONE, HEATING THE HEAVIER LIQUID IN THE EMULSION TREATING ZONE WHEREBY SAID HEAVIER LIQUID SEPARATES AND STRATIFIES INTO WATER AND CLEAN OIL LAYERS AND EVOLVES GASES AND VAPORS, WITHDRAWING WATER AND CLEAN OIL FROM THE STRATIFIED LAYERS, WITHDRAWING LIGHTER LIQUID FROM THE UPPER PORTION OF THE BODY OF LIQUID AND FLOWING THE LIGHTER LIQUID TO A STABILIZING ZONE, FLOWING GASES AND VAPORS EVOLVED IN THE EMULSION TREATING ZONE COUNTERCURRENTLY WITH THE LIGHTER LIQUID IN THE STABILIZING ZONE, WITHDRAWING GAS FROM THE STABILIZING ZONE, AND FLOWING THE LIGHTER LIQUID FROM THE STABILIZING ZONE TO THE EMULSION TREATING ZONE.
 9. A PETROLEUM EMULSION TREATING AND STABILIZING STRUCTURE INCLUDING, A GAS AND LIQUID SEPARATOR HAVING A WELL STREAM INLET AND A GAS OUTLET, MEANS FOR MAINTAINING A BODY OF SEPARATED LIQUID IN THE SEPARATOR, A FIRST OUTLET FOR WITHDRAWING A FIRST PORTION OF LIQUID FROM THE UPPER PART OF THE BODY OF LIQUID, A SECOND OUTLET FOR WITHDRAWING A SECOND PORTION OF LIQUID FROM THE LOWER PART OF THE BODY OF LIQUID, A STABILIZING STRUCTURE FOR BRINGING GAS AND LIQUID IN DIRECT AND DISPERSED CONTACT, MEANS FOR FLOWING THE FIRST PORTION OF LIQUID FROM THE FIRST OUTLET TO AND THROUGH THE STABILIZER STRUCTURE, MEANS FOR FLOWING THE SECOND PORTION OF LIQUID FROM THE SECOND OUTLET AND COMMINGLING SAID SECOND PORTION WITH THE FIRST PORTION SUBSEQUENT TO THE PASSAGE OF THE LATTER THROUGH THE STABILIZER STRUCTURE, AN EMULSION-TREATING ENCLOSURE, MEANS FOR FLOWING THE COMMINGLED LIQUID PORTIONS TO THE EMULSION TREATING ENCLOSURE, A HEATER IN THE ENCLOSURE, MEANS FOR FLOWING GAS AND VAPORS EVOLVED IN THE ENCLOSURE TO AND THROUGH THE STABILIZER STRUCTURE, AND MEANS FOR WITHDRAWING GAS AND WATER AND CLEAN OIL FROM THE STRUCTURE. 